WESTERN MIDSTREAM PARTNERS, LP (WES): what the price assumes

In the published model solve dated 2026-Q2, anchored at $46.20, WESTERN MIDSTREAM PARTNERS, LP (WES) is priced for -2.2% growth. boothcheck publishes no house fair value, target price, or buy/sell rating; individual model outputs and user-controlled scenarios are analytical inputs, not Boothcheck targets. Narrative composed 2026-06-28.

Generated: 2026-08-10 · Exported: 2026-08-12 · Source: https://boothcheck.com/report/WES

Headline

What The Price Assumes (Inversion)

The assumption today's price embeds, recovered by inverting the valuation.

The operating-margin figure is value-band context at year 12: derived from the framework's value band, a separate calculation — not part of the priced-in solve.

Solve inputs: computed at a 7.6% cost of capital with 4% terminal growth over a 5-year stage; each 1pp of cost of capital moves the implied operating-profit growth ~6.7pp.

Reconcile: at the x-ray's 9.3% required return this reads ~8.7%/yr; the models below use their own rates.

How unusual the bet is: within-range

Valuation X-Ray

The price is justified by relative-multiple and growth-DCF.

How the valuation models price the stock relative to the market price. Price/FV above 1.0 means the market pays more than that lens defends (expensive); at or below 1.0 the lens can defend the price.

Families that justify the price: Relative, Growth

The models below discount at their own flat-beta convention rates (cost of equity 9.3%, WACC 6.8%); the inversion above states its own rate.

Per-Model Detail (n=13)

Economic-Unit Decomposition (Sum Of The Parts)

Only one reportable economic unit is present in the current topology source. Consolidated operating lenses remain available, but there is no multi-unit decomposition.

No total common-equity value is stated. One or more material units lack a supported unit value. The displayed values are an indicative subtotal; consolidated debt and cash cannot be applied to a fraction of the company.

Solvency

Bullet Takeaways

• Western Midstream gathers, processes and transports natural gas, NGLs and crude under mostly fee-based contracts that give it a stable revenue stream not directly exposed to commodity prices, which is why it can pay a distribution that yields roughly 9% at today's unit price.
• The biggest risk is concentration: the partnership depends on Occidental as its largest customer and the owner of its general partner, so trouble at Occidental could raise its cost of capital and pressure its volumes.
• What to watch is throughput and the distribution: first-quarter natural gas throughput rose 2%, the partnership raised its quarterly distribution to 93 cents per unit, and management will revisit 2026 guidance after the Brazos transaction closes.

Bull Case

The reflexive worry about an energy midstream partnership is that it is just a leveraged bet on oil and gas prices, and for Western Midstream that worry is largely misplaced. The business runs on fee-based contracts, which the partnership describes as providing a relatively stable revenue stream not subject to direct commodity-price risk. Producers connect their wells to Western Midstream's gathering systems, and the partnership earns a fee for moving the volume through, recognized in the month of service based on volumes delivered. The economics that follow are not those of a commodity producer; they are those of a toll road. Operating margins run above 40%, and the cash is steady enough to fund a large, growing distribution.

That distribution is the heart of the bull case. The partnership raised its quarterly payout to 93 cents per unit in the quarter, which at the current unit price represents a yield near 9%. For an income investor, a high-single-digit cash yield backed by fee-based contracts on critical Permian infrastructure is a compelling proposition, and the first quarter showed the cash flow supporting it. Earnings of 85 cents per unit beat expectations and grew 7.6% year over year, revenue rose 22.5% to $1.1 billion, and natural gas throughput increased 2%. The throughput growth is the tell that matters most, because in a fee-based model, volume is the revenue.

The forward setup adds growth on top of yield. Management reiterated 2026 guidance of $2.5 to $2.7 billion in adjusted EBITDA and $1.85 to $2.05 billion in distributable cash flow against capital spending of $850 million to $1 billion, a profile that funds both the distribution and continued investment. The partnership is also expanding into produced-water handling and pursuing the Brazos transaction, with plans to revisit guidance once it closes. The Permian Basin remains one of the most productive oil and gas regions in the world, and a midstream operator with entrenched gathering systems there collects fees as production grows. The bull case is a high, well-covered yield attached to essential infrastructure with a volume tailwind behind it.

Bear Case

The bear case rests on a dependency the high yield is quietly compensating for, and naming it directly matters: Western Midstream is unusually tied to a single counterparty. The partnership states that it depends on Occidental as its largest customer and the owner of its general partner, and that material adverse changes at Occidental could restrict its access to capital, make the capital markets more expensive, or raise its borrowing costs. It also carries counterparty risk through non-payment or non-performance by Occidental and other customers, including minimum-volume-commitment deficiency payments. A fee-based model is only as stable as the producers feeding volume into it, and when one of those producers is both the dominant customer and the controlling owner, the partnership's fortunes are linked to that producer's drilling decisions and financial health in a way a diversified midstream operator's are not.

The second fragility is the throughput assumption baked into the yield. Fee-based revenue is stable only while volumes hold, and volumes depend on continued drilling in the Permian. The 2% throughput growth in the quarter is healthy, but Permian production growth is not guaranteed; if oil and gas prices fall enough to slow drilling, throughput flattens or declines, and the fee revenue that funds the 9% distribution comes under pressure. A distribution yielding 9% is the market telling you it perceives risk to that payout, not a gift. The partnership's distributable-cash-flow guidance covers the distribution today, but coverage thins quickly if volumes disappoint, and an MLP that cuts its distribution typically sees its units repriced sharply lower.

Leverage compounds both concerns. Net debt of roughly $8 billion sits near five times trailing operating income, with interest covered about four times. That is a normal load for a midstream partnership with steady fee income, but it ties the distribution's safety to refinancing conditions, and Western Midstream's access to capital is, by its own disclosure, partly a function of Occidental's standing. On valuation, the peer-multiple methods read the units as expensive relative to where comparable midstream operators trade, even as the cash-flow methods support the price. The bull and the bear agree the fee model is stable and the yield is high. They disagree on whether the Occidental concentration and the throughput dependency make that yield as safe as it looks, or whether the high yield is the price of those risks.

Valuation

Western Midstream is best valued on its cash distribution and the fee stream behind it rather than on a growth multiple, because the units are owned primarily for income. At $42.96 (June 28, 2026) the price embeds an assumption that the fee-based cash flow holds and the distribution near a 9% yield is sustainable, with modest throughput growth on top. The current operating margin above 40% is the toll-road economics that make that cash flow possible.

The method families split in the pattern of a value-and-income name rather than a growth bet. The cash-flow methods and the dividend-discount approach support the price; the simple dividend model in particular lands right around the unit price, which is exactly what you would expect for a high-payout partnership valued on its distribution. The earnings-power and free-cash-flow methods land near or slightly below the price, confirming the cash generation is real. The relative-valuation method is the dissenter, reading the units as expensive against where comparable midstream operators trade. That single demanding method is the market's caution about the concentration and throughput risks, not a statement that the cash flow is absent. The pattern says this is a name supported by its own cash generation, with the peer comparison flagging that it is not the cheapest way to own midstream exposure.

Leverage and counterparty concentration are the two structural facts that frame the downside. Net debt near $8 billion at roughly five times trailing operating income, with interest covered about four times, is serviceable on steady fee income but leaves the distribution sensitive to any volume shortfall, and the partnership's own access to capital is tied to Occidental's financial standing. The decisive judgment for the value is not any single method's number; it is the durability of the distribution. If Permian throughput holds and Occidental remains a healthy counterparty, the fee stream funds the payout and the units are an attractive income vehicle. If volumes slow or the controlling customer weakens, the high yield is repricing risk that has come due, and the distribution itself is what is at stake.

Catalysts

The first-quarter 2026 report was the catalyst, and it was a beat with a distribution increase. Earnings of 85 cents per unit topped the 74-cent expectation and grew 7.6% year over year, revenue rose 22.5% to $1.1 billion on higher throughputs across natural gas, crude and NGL assets, and natural gas throughput increased 2% to 5,209 million cubic feet per day. The partnership raised its quarterly distribution to 93 cents per unit and reiterated 2026 guidance of $2.5 to $2.7 billion in adjusted EBITDA and $1.85 to $2.05 billion in distributable cash flow, with capital spending of $850 million to $1 billion.

The forward catalysts are the Brazos transaction and the throughput trajectory. Management plans to revisit its 2026 guidance alongside second-quarter results after the anticipated closing of the Brazos transaction, so the deal close and the revised guidance are the next scheduled events. The partnership also started up a second produced-water handling pilot, a growth avenue to watch. The macro variable with the most leverage is Permian drilling activity, which sets the throughput volumes the fee revenue depends on, and the distribution itself is the metric income holders will track most closely each quarter. The second-quarter report and the updated guidance are the events that will show whether the cash flow continues to support the raised payout.

Peer Cohorts (Per Segment, With Filing Citations)

Western Midstream (consolidated) (reported)

• AM (ANTERO MIDSTREAM CORPORATION)
• FY2025 10-K: (1) Organization Antero Midstream Corporation together with its consolidated subsidiaries (the "Company" or "Antero Midstream"), is a growth-oriented midstream company formed to own, operate and develop midstream energy infrastructure primarily to service Antero Resources and its production and completion activity in…
• FY2025 10-K: …Midstream's ownership interest, representation on the Board of Directors and participation in the policy-making decisions of equity method investees. Such investments are included in Investments in unconsolidated affiliates on the Company's consolidated balance sheets. Income from investees that are accounted for…
• TRGP (TARGA RESOURCES CORP.)
• FY2025 10-K: …facility design and economies of scale. The Gathering and Processing segment's assets are located in the Permian Basin of West Texas and Southeast New Mexico (including the Midland, Central and Delaware Basins); the Eagle Ford Shale in South Texas; the Barnett Shale in North Texas; the Anadarko, Ardmore, and Arkoma…
• FY2025 10-K: …in consolidation. Certain amounts in prior periods have been reclassified to conform to the current year presentation. Note 3 - Significant Accounting Policies Consolidation Policy Our consolidated financial statements include the accounts of all entities that we control and our proportionate interest in the accounts…
• EPD (ENTERPRISE PRODUCTS PARTNERS L.P.)
• FY2025 10-K: …interests from affiliates of Western Midstream Partners, LP. Non-GAAP Cash Flow Measures Distributable Cash Flow and Operational Distributable Cash Flow Our partnership agreement requires us to make quarterly distributions to our common unitholders of all available cash, after any cash reserves established by…
• FY2025 10-K: …amounts presented on a gross basis. (3) We proportionately consolidate our 29% undivided interest in the approximately 520-mile Midland-to-Webster pipeline, which we refer to as the Midland-to-ECHO 3 Pipeline. The remainder of this system relates to our Midland-to-ECHO 1 Pipeline and Midland-to-ECHO 2 Pipeline, which…
• DTM (DT Midstream, Inc.)
• FY2025 10-K: Note 14 - Segment and Related Information 87 Note 15 - Related Party Transactions 90 Note 16 - Acquisition 90 Note 17 - Regulatory Matters 91 Note 18 - Subsequent Event 93 55 Report of Independent Registered Public Accounting Firm To the Board of Directors and Stockholders of DT Midstream, Inc. Opinions on the…
• FY2025 10-K: …natural gas from interconnected pipelines to power plants, local distribution companies and industrial end users. Our gathering lateral pipelines are assets that gather natural gas for our customers from multiple central delivery points within a basin and redeliver that natural gas to interstate pipelines, intrastate…
• KGS (Kodiak Gas Services, Inc.)
• FY2025 10-K: Note 3 - Acquisitions and Divestitures F- 15 Note 4 - Revenue Recognition F- 16 Note 5 - Accounts Receivable, net F- 18 Note 6 - Inventories, net F- 18 Note 7 - Property, Plant and Equipment, net F- 19 Note 8 - Goodwill and Identifiable Intangible Assets, net F- 20 Note 9 - Leases F- 20 Note 10 - Long-Lived and Other…
• FY2025 10-K: …years, depending on the customer, application, location, and size of the compression unit, with large horsepower typically contracted for a primary term of three to five years. After the expiration of the primary term, our contracts continue on a month-to-month basis until renewed or until the contract is terminated…
• NGL (NGL Energy Partners LP)
• FY2025 10-K: …us to reliably supply, store and transport products throughout the United States and Canada. • Our contracted operations allow us to generate more predictable and stable cash flows on a year-to-year basis. Our ability to provide multiple services to customers enhances our competitive position. Our three business…
• FY2025 10-K: …financial statements. F-8 NGL ENERGY PARTNERS LP AND SUBSIDIARIES Notes to Consolidated Financial Statements Note 1- Organization and Operations NGL Energy Partners LP, a Delaware master limited partnership ("we," "us," "our," or the "Partnership"), was formed in September 2010. NGL Energy Holdings LLC serves as our…
• USAC (USA Compression Partners, LP)
• FY2025 10-K: …compression requirements and those of third-party customers. Our Relationship with Energy Transfer LP We share certain services with the owner of our General Partner, Energy Transfer. Under this shared service model, we share personnel and resources in certain departments, including information technology,…
• FY2025 10-K: …services, such as carbon dioxide and hydrogen sulfide removal and natural gas cooling and dehydration, to natural gas producers and midstream companies. Additionally, as a result of the J-W Power Acquisition, we also own and operate specialized manufacturing facilities for the manufacture of compression units. Our…

Methodology Note

• Priced-in inversion: the valuation is inverted on the current price to recover the operating-income growth, duration, and steady-state margin the price embeds (ROE for financials, FFO growth for REITs).
• Valuation x-ray: the valuation models, grouped into four families (asset, earnings, relative, growth). Each model is expressed as a price/FV ratio (distance from price), not a point fair-value estimate. The spread across families is the disagreement.
• Economic-unit decomposition (SOTP): each disclosed business unit is assigned its native valuation basis before any multiple is applied. Operating units are valued on enterprise value; funded financial units are valued on their own common equity, because their borrowings fund earning assets rather than levering the parent. A company total is stated only once every material unit carries a supported value and the parent capital bridge reconciles.
• Solvency: net cash/debt, net-debt-to-NOPAT, interest coverage, and share-count CAGR from EDGAR financials (net debt / FFO and fixed-charge coverage for REITs; regulatory-capital framing for financials).
• Peer cohorts: per-segment comparables with deep-linkable SEC filing citations.

Fundamentals sourced from SEC EDGAR filings. Current price from Databento. The priced-in inversion and valuation x-ray are computed by the boothcheck engine; narrative composed by AI from the structured data.